Apparatus and method for manipulating fluid during drilling or pumping operations

ABSTRACT

A method and apparatus for manipulating fluid, such as measuring bubble point, during drilling or pumping operations including pumping fluid in a borehole through a flow line ( 200 ) and drawing fluid from the flow line through an isolation line ( 232 ) without substantially dropping pressure of the flow line or without ceasing pumping operations.

FIELD

The subject matter relates to formation testing, and more particularly,to manipulation of fluid during drilling or pumping operations.

BACKGROUND

In drilling a wellbore, drilling fluid is used to facilitate thedrilling process and to maintain a hydrostatic pressure in the wellboregreater than the pressure in the formations surrounding the wellbore.The drilling fluid penetrates into or invades the formations dependingupon the types of the formation and drilling fluid used. The formationtesting tools retrieve formation fluids from the desired formations orzones of interest, test the retrieved fluids to ensure that theretrieved fluid is substantially free of filtrates. The testing toolsfurther collect fluids, for example, in one or more chambers associatedwith the tool. The collected fluids are brought to the surface andanalyzed to determine properties of such fluids and to determine theconditions of the zones or formations from where such fluids have beencollected. In order to properly analyze the samples, it is importantthat only uncontaminated fluids are collected in the same condition inwhich they exist in the formation. For example, the fluid is maintainedin a single phase, which is done by maintaining the pressure of thefluid constantly above the bubble point.

Conventional formation tester tools may need to manipulate the samplefluid to make fluid property measurements such as the bubble point byperiodically measuring the static bubble point. This requires thepumping operation to cease during the fluid measurement, allowingcontamination to encroach into the sample zone, and further slowing theoverall pumping process.

Accordingly, what is needed is a testing operation or pumping operationthat does not require the pumping operation to cease while testing thefluid.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates a system for drilling operations as constructed inaccordance with at least one embodiment.

FIG. 2 illustrates a block diagram of a portion of the system asconstructed in accordance with at least one embodiment.

FIG. 3 illustrates a flow chart in accordance with at least oneembodiment.

FIG. 4A illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 4B illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 4C illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 4D illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 5A illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 5B illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 5C illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 5D illustrates a measurement module as constructed in accordancewith at least one embodiment.

FIG. 5E illustrates a measurement module as constructed in accordancewith at least one embodiment.

DESCRIPTION

In the following description of some embodiments of the presentinvention, reference is made to the accompanying drawings which form apart hereof, and in which are shown, by way of illustration, specificembodiments of the present invention which may be practiced. In thedrawings, like numerals describe substantially similar componentsthroughout the several views. These embodiments are described insufficient detail to enable those skilled in the art to practice thepresent invention. Other embodiments may be utilized and structural,logical, and electrical changes may be made without departing from thescope of the present invention. The following detailed description isnot to be taken in a limiting sense, and the scope of the presentinvention is defined only by the appended claims, along with the fullscope of equivalents to which such claims are entitled.

FIG. 1 illustrates a system 100 for drilling operations. It should benoted that the system 100 can also include a system for pumpingoperations, or other operations. The system 100 includes a drilling rig102 located at a surface 104 of a well. The drilling rig 102 providessupport for a down hole apparatus, including a drill string 108. Thedrill string 108 penetrates a rotary table 110 for drilling a borehole112 through subsurface formations 114. The drill string 108 includes aKelly 116 (in the upper portion), a drill pipe 118 and a bottom holeassembly 120 (located at the lower portion of the drill pipe 118). Thebottom hole assembly 120 may include drill collars 122, a downhole tool124 and a drill bit 126. The downhole tool 124 may be any of a number ofdifferent types of tools including measurement-while-drilling (MWD)tools, logging-while-drilling (LWD) tools, etc.

During drilling operations, the drill string 108 (including the Kelly116, the drill pipe 118 and the bottom hole assembly 120) may be rotatedby the rotary table 110. In addition or alternative to such rotation,the bottom hole assembly 120 may also be rotated by a motor that isdownhole. The drill collars 122 may be used to add weight to the drillbit 126. The drill collars 122 also optionally stiffen the bottom holeassembly 120 allowing the bottom hole assembly 120 to transfer theweight to the drill bit 126. The weight provided by the drill collars122 also assists the drill bit 126 in the penetration of the surface 104and the subsurface formations 114.

During drilling operations, a mud pump 132 optionally pumps drillingfluid, for example, drilling mud, from a mud pit 134 through a hose 136into the drill pipe 118 down to the drill bit 126. The drilling fluidcan flow out from the drill bit 126 and return back to the surfacethrough an annular area 140 between the drill pipe 118 and the sides ofthe borehole 112. The drilling fluid may then be returned to the mud pit134, for example via pipe 137, and the fluid is filtered. The drillingfluid cools the drill bit 126 as well as provides for lubrication of thedrill bit 126 during the drilling operation. Additionally, the drillingfluid removes the cuttings of the subsurface formations 114 created bythe drill bit 126.

The downhole tool 124 may include one to a number of different sensors145, which monitor different downhole parameters and generate data thatis stored within one or more different storage mediums within thedownhole tool 124. The type of downhole tool 124 and the type of sensors145 thereon may be dependent on the type of downhole parameters beingmeasured. Such parameters may include the downhole temperature andpressure, the various characteristics of the subsurface formations (suchas resistivity, radiation, density, porosity, etc.), the characteristicsof the borehole (e.g., size, shape, etc.), etc.

The downhole tool 124 further includes a power source 149, such as abattery or generator. A generator could be powered either hydraulicallyor by the rotary power of the drill string. The downhole tool 124includes a formation testing tool 150, which can be powered by powersource 149. In an embodiment, the formation testing tool 150 is mountedon a drill collar 122. The formation testing tool 150 engages the wallof the borehole 112 and extracts a sample of the fluid in the adjacentformation via a flow line. As will be described later in greater detail,the formation testing tool 150 samples the formation and inserts a fluidsample in a sample carrier 155. The tool 150 injects the carrier 155into the return mud stream that is flowing intermediate the boreholewall 112 and the drill string 108, shown as drill collars 122 in FIG. 1.The sample carrier(s) 155 flow in the return mud stream to the surfaceand to mud pit or reservoir 134. A carrier extraction unit 160 isprovided in the reservoir 134, in an embodiment. The carrier extractionunit 160 removes the carrier(s) 155 from the drilling mud.

FIG. 1 further illustrates an embodiment of a wireline system 170 thatincludes a downhole tool body 171 coupled to a base 176 by a loggingcable 174. The logging cable 174 may include, but is not limited to, awireline (multiple power and communication lines), a mono-cable (asingle conductor), and a slick-line (no conductors for power orcommunications). The base 176 is positioned above ground and optionallyincludes support devices, communication devices, and computing devices.The tool body 171 houses a formation testing tool 150 that acquiressamples from the formation. In an embodiment, the power source 149 ispositioned in the tool body 171 to provide power to the formationtesting tool 150. The tool body 171 may further include additionaltesting equipment 172. In operation, a wireline system 170 is typicallysent downhole after the completion of a portion of the drilling. Morespecifically, the drill string 108 creates a borehole 112. The drillstring is removed and the wireline system 170 is inserted into theborehole 112.

Referring to FIG. 2, the system 100 includes a main flow line 200through which pumping operations occur, and/or fluid sampling occurs.The system further includes a measurement module 230 coupled with themain flow line 200. The measurement module 230 includes an isolationline 232 and an apparatus or method for drawing fluid through theisolation line 232. For example, the measurement module 230 includes atleast one isolation pump 234. The at least one isolation pump 234includes, but is not limited to, a single piston pump, a dualreciprocating pump, or a combination thereof. In another option, themeasurement module does not need a piston to draw fluid into themeasurement module. For example, the measurement module 230 includes acentrifuge to create flow through the isolation line 232. In anotheroption, a flow is produced through the isolation line 232 using aparallel path, for example, using the flow produced by another pump,such as a pump independent from the measurement module 230. Optionally,isolated measurements are made by bombarding the fluid acoustically,magnetically, using radiation or vibration or other methods to makemeasurements.

The measurement module 230 is used to manipulate a fluid independent ofthe flow line 200, for example, to determine the bubble point of thefluid, or other properties. Various methods can be used to measure thebubble point. In an example method, a piston gradually reduces pressurein a chamber where a sample is contained, while the pressure in thechamber is monitored. The pressure is reduced by increasing the volumein the chamber (e.g. cylinder), for example by retracting a pistonwithin the chamber. The pressure of the chamber is monitored, and abubble point may be determined by analyzing the pressure versus volumerelationship.

The measurement module 230 can be used to manipulate a fluid of the flowline 200, without affecting the operation of the flow line 200 while thefluid is manipulated. For example, during pumping operations, fluid canbe pumped or sampled via the flow line 200, and the measurement module230 is used to manipulate the fluid without having to stop operation ofthe flow line 200, for example. In another example, the measurementmodule 230 can be used to manipulate the fluid of the flow line 200without substantially dropping the pressure significantly within theflow line 200.

Referring to FIGS. 2, 4A, and 5A, the pump 234, or other measures forcreating flow in the isolation line, is isolated from the flow line 200and optionally the borehole (FIG. 1) via, for example, one or moredevices that can cease or otherwise restrict flow to the isolation line,for example, isolation valves 236. It should be noted that other devicesother than valves can be used and are contemplated herein, such as, butnot limited to, flow blockers, flow restrictors, etc., or any method tocontrol movement of fluid. When the one or more isolation valves 236, orother devices, are opened, fluid can be drawn from the flow line 200 andinto a chamber of the measurement module 230. Once the chamber hassufficient sample fluid for manipulation, for example, sufficient toperform a bubble point measurement, the one or more isolation valves236, or other devices, can be closed allowing the fluid to bemanipulated, for example to obtain a bubble point. The measurementmodule 230 further optionally includes one or more exhaust isolationvalves 238 that can be opened and the used sample fluid is expelled intothe borehole, and optionally may be expelled through a check valve. In afurther option, valve 238 is a check valve, or includes other structureto limit the flow of fluid in one direction. It should be noted thatother devices can be used in place of valves 238 or in combination withvalves 238, such as, but not limited to flow blockers, flow restrictors,etc. The pressure before, between, or after the valves 236, 238 isoptionally equalized before they are open for one or both of the inletand exhaust processes.

FIG. 3 illustrates a flow chart of the process for manipulating thefluid. At 280, the borehole is drilled as further discussed above. At288, drilling continues to occur, where the drilling includes, but isnot limited to, down hole sampling. Alternatively, or in combinationwith drilling and/or sampling, at 288 pumping operations are occurringvia the flowline. The pumping operation is taking place in attempt topurge the “packed-off” formation of interest (at pad 231) of drillingfluid filtrate in order to access true, uncontaminated formation fluids.Once the pumping has achieved a steady state flowing condition from theformation, it is detrimental or counterproductive to halt the pumping toobtain fluid property measurements.

At 282, fluid is drawn from the flow line, for example, but not limitedto, with a pump. Various examples of ways of drawing flow from the flowline, such as with pumps are discussed above and below. For instance,pumps with a single chamber or pumps with multiple chambers can be used.Alternatively, or in combination with pumps, other methods for producingflow can be used. Notably, drawing fluid from the flow line, although isnot mandatory, can occur without stopping other processes, such as thepumping process. Drawing the fluid from the flow line does notsubstantially affect the flow line, such that it can be done when theflow line is being used for another process, such as, but not limitedto, pumping. At 284, the fluid is manipulated outside of the flow line.For example, a bubble point measurement is taken, as further discussedbelow. At 286, the fluid is expelled, for example, into the borehole.

The method allows for the ability to extract a portion of the pumpedfluid from the flowline in order to make relatively continuousmeasurements regarding the quality of the flowline fluids without havingto stop the primary pumping operation. The process can be repeated, asshown in FIG. 3. The method allows for the bubble point to be measuredfrequently, such as every 1 to 5 minutes.

FIGS. 4A-4C illustrate an example use of an example embodiment. FIG. 4Aillustrates a measurement module 230 with a pump 234 such as a singlepiston pump, and further including an isolation valve 236 and an exhaustisolation valve 238. The piston 290 of the pump 234 is moved to equalizethe pressure across the isolation valve 236. This pressure equalizationis indicated by the measurements of the test chamber pressure transducer242 and the flowline pressure transducer 244. The valve 236 is placed inthe open position allowing for the chamber 240 to intake fluid from theflowline (FIG. 4B) via pad 231 and the isolation line 232. The samplefluid is drawn into the chamber 240 at a rate so as to not substantiallydrop the pressure of the flowline (FIG. 4B). In an example, the flowlinepressure is not dropped more than 1-4 psi. In another example, theflowline pressure is not dropped below the bubble point. In yet anotherexample, the fluid is drawn at a rate of about 0.1 cc/sec, for example,to ensure the pressure is not dropped in heavy oil or low permeabilityrocks.

When sufficient fluid sample has been acquired to perform a desiredmeasurement or fluid manipulation, the valve 236 can be closed. In anexample, the piston 290 is moved to increase the volume in the chamber,and the trapped fluid will be gradually reduced in pressure by theincrease in volume. A gauge optionally monitors one or more conditionsof the fluid, for example the pressure and the gradient of the fluid,and a determination of the bubble point will be detected. Optionally,the measurement module 230 further may include a relief valve from theisolation line to ensure the reduction of pressure is not too greatduring the decompression phase after the bubble point is detected.Optionally the pressure is equalized again using the piston 290.Referring to FIG. 4C, the exhaust isolation valve 238 is opened and themanipulated sample fluid is expelled from the chamber 240 and into theborehole, or collected, or move to another measurement process.Additional measurements and/or manipulations include, but are notlimited to, pressure, acoustic, radiation, light, heat and vibration. Ifdesired, the manipulated fluid may be expelled back into flowline 200via isolation line 232 by re-opening isolation valve 236 and movingpiston 290 in the closed direction. If this method is utilized, thepressure across isolation valve 236 is equalized prior to opening.

It should be noted in FIGS. 4A-4C that isolation line 232 is connectedto flowline 200 between the fluid point of entry and the inlet to thedownhole pump. The pressure within the isolation line 232 is the“flowing” pressure from the “packed-off” formation of interest withinflowline 200. With the isolation line 232 connected to flowline 200 atthe inlet side 245 of the pump 247, pressure equalization acrossisolation valve 236 prevents disruptive pressure spikes (either positiveor negative) from propagating through flowline 200 to the “packed-off”formation of interest at pad 231. FIG. 4D shows an alternateconfiguration which eases the equalization requirement across isolationvalve 236. In this configuration, the isolation line 232 is connected tothe flowline 200 at the outlet side 249 of the pump 247. The pressure inflowline 200 at the outlet side 249 of the pump 247 is typically at thehydrostatic pressure of the wellbore (outside of the packed-offformation) and therefore, pressure fluctuations as a result of operationof isolation valve 236 are not as disruptive.

FIGS. 5A-5D illustrate another example of a measurement module 230 inwhich a dual reciprocating pump 233 is used for the pump 234. Themeasurement module 230, in an option, includes at least one chamber,such as two chambers 240, 241 performing the same operations out ofsequence to double the effectiveness of the sampling process, as shownin FIG. 5A. It should be noted that multiple pumps and/or multiplechambers can be used with the measurement module 230 for furtherefficient testing of the fluid.

The measurement module 230 further includes a hydraulic closed loopcontrol system, in an option, which is what drives the dualreciprocating pump 233. This can be run in tandem with an existing pumpeither independently or synchronized. In yet another option, themeasurement module 230 includes a hydraulic controller 260. In anoption, hydraulic controller 260 controls the dual reciprocating pump233 at a ratio proportionate to a volume being pumped in the flowline200 and at a rate required to obtain a bubble point measurement. Forexample, a ratio of 10:1 when the pump rate ranges from about 0.1 cc/secto 68 cc/sec, and the chamber would be about 0.01 to 6.8 cc/sec. Inanother option, the measurement module 230 stroke time is synchronizedto another pumping device, such as the main pump (FIG. 1) and at astroke phase relationship to reduce the effects of fluid draw and/ormanipulation, such as bubble point measurement.

The measurement module 230 includes isolation valves 236 a and 236 b,such as a high pressure valve, that controls the flow of fluid from theflow line 200 into the chambers 240, 241. It should be noted thatdevices other than a valve can be used, such as restrictors. The exhaustisolation valves 238 a and 238 b control the exhaust of fluids from themeasurement module, and into the bore hole, for example. The valves 236a, 236 b, 238 a, 238 b are optionally controlled by the hydrauliccontroller 260 and are monitored, for example, by a potentiometer. In anoption, the sequencing of the valve(s) compared to the piston 290position will be timed to ensure the measurement effectiveness and thestability of the measure fluid and controlled by hydraulic controller260. The measurement module 230 further includes sensors such as, butnot limited to, pressure and/or fluid temperature sensors 242 and 243.The pressure sensors 242 and 243 have, in an option, an adequatetolerance to measure the fluid phase shift to detect a bubble point atthe set operating range of the isolation pump. Other options includeadditional sensors to detect changes in the fluid due to the compressionand/or decompression phase of the measurement.

FIG. 5A illustrates the intake phase of chamber 240 and correspondingly,the pressure equalizing phase of chamber 241. The isolation valve 236 afor the chamber 240 is opened and the exhaust valve 238 a is closed.Both the isolation valve 236 b and exhaust valve 238 b for chamber 241are closed. The piston 290 travels in the direction of the arrow. As thepiston 290 travels in this direction within the pump 233, fluid is drawnfrom the flow line 200 into chamber 240 at a rate, for example, set bythe hydraulic controller 260. At the same time, the motion of piston290, which expands volume of chamber 240, serves to contract the volumeof chamber 241. This reduction in volume serves to equalize the pressureacross exhaust valve 238 b. The valve sequence will allow fluid to bedrawn from the flow line 200 at pumping pressure, and the volume drawnwill not cause a significant reduction of flow line pressure, or willnot substantially affect flow line pressure. In an example, the flowline pressure is not affected by more than 1 psi. In another example,the ratio of volumetric flowrate in the flow line to the isolation lineis 10:1. In another option, the ratio is in the range of about 20:1. Thevalve 236 a is opened at the start of the stroke of the piston 290, andis closed at approximately halfway through the upward stroke of piston290 (see FIG. 5B). At approximately the same time, exhaust valve 238 bof chamber 241 is opened. Continued controlled travel of piston 290expands the sealed off volume of chamber 240 thereby reducing thepressure of the contained fluid sample. By monitoring the pressure ofthe contained sample, by means of pressure transducer 242, with respectto the change in volume of chamber 240, the bubble point of the samplemay be measured. At the same time, this motion of the piston 290 alsoexpels the previously manipulated sample contained in chamber 241through the open exhaust valve 238 b.

Referring to FIG. 5C, the piston 290 is traveling in the oppositedirection of FIG. 5A and FIG. 5B, where the piston 290 is traveling inthe direction of the arrow shown in FIG. 5C. The isolation valve 236 aand exhaust valve 238 a of chamber 240 is closed. At approximately thesame time, isolation valve 236 b of chamber 241 is opened. The motion ofpiston 290 in the direction of the arrow on FIG. 5C reduces the volumeof the previously expanded sample contained in chamber 240 and acts toequalize the pressure across the exhaust valve 238 a. At the same time,the motion of piston 290 will expand the volume of chamber 241 and drawa volume of sample fluid from flowline 200 through the open isolationvalve 236 b. At approximately halfway through the stroke of piston 290,exhaust valve 238 a of chamber 240 will open and isolation valve 236 bof chamber 241 will close (see FIG. 5D). Continued motion of piston 290will expel the previously manipulated sample in chamber 240 through theopen exhaust valve 238 b and at the same time, expand the collectedsample in chamber 241. As before, by monitoring the pressure of thecontained sample in chamber 241, by means of pressure transducer 243,with respect to the change in volume of chamber 241, the bubble point ofthe sample may be measured.

The reciprocating piston-style chamber arrangement allows for twoseparate test chambers to be performing bubble point tests out of phasefrom one another (i.e. while chamber 240 is expanding the sample todetermine the bubble point pressure, chamber 241 is expelling apreviously tested sample).

The piston 290 travels within the pump, and the chambers 240, 241, andeach of the chambers undergoes a change in activity, as described asfollows.

-   -   1) sample intake—the test chamber is filled from the flowline at        a controlled rate;    -   2) (Optional Step) sample compression—the sample is compressed        until the sample pressure is at a predetermined value equal to        or above hydrostatic pressure;    -   3) sample expansion—the contained sample volume is expanded at a        controlled rate; resulting sample pressure versus volume change        recorded, i.e. bubble point measurement;    -   4) sample pressure equalization—the pressure inside the test        chamber is equalized to the exhaust line pressure;    -   5) expel sample—sample is expelled through the exhaust valve to        the wellbore or to additional sensors at a controlled rate.

The following table illustrates the “out of phase” bubble point testingsequences of the reciprocating piston, dual chamber test arrangement.The reciprocating piston position is approximate, or in the alternativeexact.

Approx. Chamber 240 Chamber 241 Piston Isolation Exhaust IsolationExhaust Position Valve Valve Valve Valve (% of Stroke) Step ActivityPosition Position Step Activity Position Position 0 → 50% 1 Intake OpenClose 4a Equalize Close Close 50 → 45%  2 Compress Close Close 4b CloseClose 45 →100% 3 Expand Close Close 5 Expel Close Open 100 →50%  4aEqualize Close Close 1 Intake Open Close 50 → 55%  4b Close Close 2Compress Close Close 55 → 0%  5 Expel Close Open 3 Expand Close Close 0→ 50% 1 Intake Open Close 4a Equalize Close Close 50 → 45%  2 CompressClose Close 4b Close Close 45 → 100% 3 Expand Close Close 5 Expel CloseOpen 100 → 50%  4a Equalize Close Close 1 Intake Open Close 50 → 55%  4bClose Close 2 Compress Close Close 55 → 0%  5 Expel Close Open 3 ExpandClose Close 0 → 50% 1 Intake Open Close 4a Equalize Close Close 50 →45%  2 Compress Close Close 4b Close Close 45 → 100% 3 Expand CloseClose 5 Expel Close Open

If desired, the manipulated fluid may be expelled back into flowline 200via isolation line 232 by re-opening isolation valve 236 a or 236 b andmoving piston 290 in the direction to minimize the volume of eitherchamber 240 or 241. If this method is utilized, the pressure acrossisolation valve 236 a or 236 b is equalized prior to opening.

It should be noted in FIGS. 5A-5D that isolation line 232 is connectedto flowline 200 between the fluid point of entry at pad 231 and theinlet to the downhole pump. The pressure within the isolation line 232is the “flowing” pressure from the “packed-off” formation of interestwithin flowline 200. With the isolation line 232 connected to flowline200 at the inlet side of the pump, pressure equalization acrossisolation valves 236 a and 236 b prevents disruptive pressure spikes(either positive or negative) from propagating through flowline 200 tothe “packed-off” formation of interest at packer 231. FIG. 5E shows analternate configuration which eases the equalization requirement acrossisolation valves 236 a and 236 b. In this configuration, the isolationline 232 is connected to the flowline 200 at the outlet side of thepump. The pressure in flowline 200 at the outlet side of the pump istypically at the hydrostatic pressure of the wellbore (outside of thepacked-off formation) and therefore, pressure fluctuations as a resultof operation of isolation valves 236 a and 236 b are not as disruptive.

Advantageously, the bubble point of the fluid being pumped and/or testedcan be determined without affecting the pumping operations, or thedrilling operations, or without having to cease the pumping or drillingoperations, or without having to drop the flowline pressure below thebubble point in the sample flowline. This can increase the efficiency ofthe pumping or drilling operations. Furthermore, the bubble point can beobtained without the need to re-inject manipulated fluid or gas into theflow line. Samples can be obtained with low levels of contamination.

Reference in the specification to “an option,” “an embodiment,” “oneembodiment,” “some embodiments,” or “other embodiments” means that aparticular feature, structure, or characteristic described in connectionwith the options or embodiments is included in at least someembodiments, but not necessarily all embodiments, of the invention. Thevarious appearances of “an embodiment,” “one embodiment,” or “someembodiments” are not necessarily all referring to the same embodiments.

Although specific embodiments have been described and illustratedherein, it will be appreciated by those skilled in the art, having thebenefit of the present disclosure, that any arrangement which isintended to achieve the same purpose may be substituted for a specificembodiment shown. This application is intended to cover any adaptationsor variations of the present invention. Therefore, it is intended thatthis invention be limited only by the claims and the equivalentsthereof.

1. A method comprising: pumping fluid in a borehole through a flow line with a down hole apparatus, the down hole apparatus including a down hole apparatus pump; drawing fluid from the flow line through an isolation line without substantially dropping pressure of the flow line, where fluid is pumped through the flow line while fluid is drawn from the flow line; manipulating the fluid drawn from the flow line; and expelling the manipulated fluid.
 2. The method as recited in claim 1, wherein manipulating the fluid includes obtaining a bubble point of the fluid.
 3. The method as recited in claim 1, wherein manipulating the fluid includes testing the fluid.
 4. The method as recited in claim 3, wherein testing the fluid includes testing at least one of pressure or temperature of the fluid.
 5. The method as recited in claim 1, wherein expelling the manipulated fluid includes expelling the manipulated fluid into at least one of the bore hole, or a chamber, or a vessel.
 6. The method as recited in claim 1, wherein drawing fluid from the flow line includes drawing the fluid with at least one of a reciprocating pump, a single piston pump, a dual reciprocating pump, or a receiving vessel.
 7. The method as recited in claim 1, wherein drawing fluid from the flow line through an isolation line includes drawing fluid through a first isolation line, and drawing fluid through a second isolation line out of sequence from the first isolation line.
 8. The method as recited in claim, further comprising opening one or more valves before drawing fluid from the flow line.
 9. The method as recited in claim 8, further comprising equalizing pressure across the one or more valves before opening the one or more valves.
 10. The method as recited in claim 1, wherein drawing fluid through the isolation line includes drawing fluid with an isolation line pump, and synchronizing the isolation line pump with the downhole sampling apparatus pump.
 11. An apparatus comprising: a down hole apparatus including a flow line pump and a bore hole flow line, the bore hole flow line operatable at a bore hole flow line pressure; the flow line pump coupled with the bore hole flow line; and means for drawing sample fluid from the bore hole flow line while fluid is pumped through the flow line without substantially dropping pressure in the bore hole flow line.
 12. The apparatus as recited in claim 11, wherein the means for drawing sample fluid includes a means for measuring bubble point of the fluid while operating the flow line pump.
 13. The apparatus as recited in claim 11, wherein the means for drawing sample fluid further includes at least one or more of a temperature sensor or a pressure sensor.
 14. The apparatus as recited in claim 11, wherein the means for drawing sample fluid includes a pump synchronized with the flow line pump.
 15. The apparatus as recited in claim 11, wherein the means for drawing sample fluid includes at least one or more of a single piston pump or a dual reciprocating pump.
 16. An apparatus comprising: a down hole apparatus including a flow line pump and a bore hole flow line, the bore hole flow line operatable at a bore hole flow line pressure; the flow line pump coupled with the bore hole flow line; a measurement module including at least one isolation line and at least one isolation pump; at least one isolation pump coupled with the isolation line; the isolation line communicatively coupled with the bore hole flow line; and the isolation line operatable in tandem with the down hole apparatus without substantially affecting the bore hole flow line pressure.
 17. The apparatus as recited in claim 16, further comprising at least one or a pressure sensor or a temperature sensor associated with the isolation line.
 18. The apparatus as recited in claim 16, wherein the measurement module determines a bubble point of drawn fluid in the measurement module while the flow line pumps fluid through the bore hole flow line.
 19. The apparatus as recited in claim 16, wherein the isolation pump is synchronized with the flow line pump.
 20. The apparatus as recited in claim 16, further comprising two or more isolation pumps, and at least two of the isolation pumps are operatable out of sequence with each other.
 21. The apparatus as recited in claim 16, wherein the at least one isolation pump is at least one of a single piston pump or a dual reciprocating pump. 